Each project aims to demonstrate integrated carbon capture, transport and storage technologies and infrastructure that can be deployed at power plants. However, the technologies and environments are different. In this case, three novel solvents would be demonstrated and combined with carbon transport and storage in different geological settings.

Funding for the projects – in California, North Dakota and Texas – comes from the Bipartisan Infrastructure Law signed in 2021.

The Biden Administration believes the large-scale deployment of carbon capture, transport and storage infrastructure could play a vital role in reducing emissions in the U.S. For more than a decade the federal government has provided financial support to boost the development and use of technologies for capturing CO2 emissions.

But in the last couple of years, legislation has significantly increased annual funding for these efforts. The Bipartisan Infrastructure Law, formally known as the Infrastructure Investment and Jobs Act, provides $8.2 billion in advance appropriations for CCS programs over the 2022–2026 period, according to a recent Congressional Budget Office (CBO) report.

Proponents say carbon capture could have a huge role in reducing emissions, while many environmentalists note the technology is far from scale and argue that focusing on it distracts from renewable energy solutions.

According to the CBO report, 15 CCS facilities are currently operating in the U.S. Together, they have the capacity to capture 0.4 percent of the nation’s total annual CO2 emissions.

The report notes an additional 121 CCS facilities are under construction or in development. If all were completed, they would increase the nation’s CCS capacity to 3 percent of current annual CO2 emissions.

Here are the three projects selected for award negotiation: 

Baytown Carbon Capture and Storage Project

The Baytown Carbon Capture and Storage (CCS) Project plans to capture CO2 from the Baytown Energy Center, a natural gas combined-cycle plant in Baytown, Texas. The project would use Shell’s CANSOLV solvent to capture CO2, which would be transported through new and existing pipelines and sequestered in storage sites on the Gulf Coast.

Calpine is serving as the lead for the Baytown CCS project and Covestro, an industrial manufacturer of plastics, will serve as the project’s primary power off-taker. Calpine expects the project will capture up to 2 million metric tons of CO2 per year

The project is also considering the use of greywater cooling to minimize freshwater consumption by reusing wastewater, according to DOE.

The 896 MW Baytown Energy Center provides steam and power to the adjacent Covestro chemicals manufacturing facility as well as power to the Texas electric grid.

Calpine said adding post-combustion carbon capture equipment to this facility would reduce the carbon dioxide emissions intensity of two of its three combustion turbines at a design capture rate of 95%.

Calpine has a total of 11 CCS projects in its pipeline.  

In July 2022 the company unveiled a carbon capture demonstration pilot project at its combined-cycle plant in Pittsburg, California. The CCS project at Calpine’s Los Medanos Energy Center will use a chemical solvent developed by ION Clean Energy to bind with carbon dioxide in the plant’s flue gas.

In the case of this pilot, the project will not store the captured carbon and instead release it back into atmosphere. However, in future plants, the CO2 could be pumped and stored underground.

Project Tundra

Project Tundra is a carbon capture system to be developed adjacent to the Milton R. Young Station, a coal-fired plant near Center, North Dakota. The project plans to use Mitsubishi Heavy Industries’ KS-21 solvent to capture CO2, which would be permanently stored in saline geologic formations beneath and surrounding the power plant. The storage site has already been approved for a Class VI well permit.

Project Tundra is being developed by project sponsors which include Minnkota Power Cooperative and TC Energy. The project is expected to capture an annual average of 4 million metric tons of CO2.

Minnkota said it plans to retrofit the coal-fired plant’s 430 MW Unit 2 to capture up to 90% of its CO2 emissions. Unit 2 is a cyclone-fired wet bottom boiler from Babcock & Wilcox.

MHI will collaborate on the CO2 capture facility with Kiewit, which will construct the project.

Project Tundra is receiving up to $350 million.

Sutter Decarbonization Project

The Sutter Decarbonization Project plans to demonstrate and deploy a carbon capture system at the Sutter Energy Center, a 550 MW combined-cycle plant near Yuba City, California. The project would use ION’s ICE-21 solvent to capture the CO2 and sequester it permanently more than a half a mile underground in saline geologic formations.

This project would be the first in the world to deploy an air-cooling system at a carbon capture facility, which will eliminate the use of cooling water and significantly minimize freshwater usage—a critical concern of the local community.

The Sutter Decarbonization Project will receive up to $270 million. Sutter CCUS (a subsidiary of Calpine) is developing the project.  

Funding applicants were required to submit Community Benefits Plans, intended to spur community and labor engagement in carbon management technologies while addressing environmental burdens in partnership with surrounding communities.

DOE estimates that reaching the current administration’s plan for a net-zero emissions economy would require capturing and storing between 400 million and 1.8 billion metric tons of CO2 annually by 2050. The power sector accounts for more than a quarter of U.S. carbon emissions.

According to the CBO report, the future adoption of carbon capture and storage depends on a variety of factors, like changes in the cost to capture CO2, the availability of pipeline networks and storage capacity for transporting and storing CO2, federal and state regulatory decisions and the development of clean energy technologies that could affect the demand for CCS.

DOE said it will host a national briefing on Dec. 18 to share more information about the selected projects. A period of stakeholder engagement will then take place starting in January. 

The testing was conducted using combustion test equipment at the Nagasaki District Research & Innovation Center in Nagasaki, the company said. Utilizing a combustion test furnace with a fuel consumption of 0.5 tons per hour (t/h), MHI says it conducted a single-fuel burner test using an ammonia burner, and a high-ratio ammonia co-firing test with coal. In both cases, MHI said the tests confirmed stable combustion, reduced nitrogen oxide (NOx) emissions compared to coal firing, and complete combustion of the ammonia.

Mitsubishi Power is developing its H-25 gas turbine that would be fueled 100 percent by ammonia, and the company hopes to bring it to commercialization by 2025.

In addition to its role as an energy carrier allowing transport and storage of hydrogen energy at low cost, ammonia can be used directly as a fuel for thermal power generation, and because it does not emit CO2 during combustion, is expected to contribute to the reduction of greenhouse gas emissions.

A challenge needing to be addressed with direct combustion of ammonia is the production of nitrogen oxide (NOx) caused by oxidation resulting from the combustion of the nitrogen component of the fuel. Mitsubishi Power said it is aiming to resolve this issue through the commercialization of a gas turbine system that combines selective catalytic reduction with a newly developed combustor that reduces NOx emissions, for installation in the Company’s H-25 Series gas turbines.

As a next step, MHI plans to conduct a combustion test using an actual-sized burner in a larger 4t/h combustion test furnace. Based on these results, MHI will then take steps for the application of the burner it has developed for thermal power plants in Japan and overseas.

Since fiscal 2021, MHI has been pursuing “development and demonstration of high-ratio ammonia co-firing technology in coal-fired boilers” as part of the Fuel Ammonia Supply Chain Establishment project conducted by the Green Innovation Fund Project of the New Energy and Industrial Technology Development Organization (NEDO). This combustion test is part of that project, and by fiscal 2024, MHI says it plans to develop burners capable of ammonia single-fuel firing for both circular firing and opposed firing type burners.

The Nagasaki District Research & Innovation Center, where the test was conducted, is located in Nagasaki Carbon Neutral Park, MHI Group’s development base for energy decarbonization technologies that commenced operations in August this year. With the success of this combustion test, MHI is accelerating the development of related technologies for practical application in thermal power generation boilers in Japan and overseas.

Last year, Mitsubishi announced plans to research ammonia-based power generation in Indonesia and Singapore.

Mitsubishi Power and Indonesia’s Institut Teknologi Bandung (ITB) plan to research firing ammonia in gas turbines under a new agreement. The collaboration between Mitsubishi Power and ITB stems from a 2020 agreement to study next-generation clean energy solutions at power plants. Research and development of ammonia-fired power generation will be conducted at ITB facilities.

Mitsubishi Power said the aims of the partnership include promoting technology development between Japan and Indonesia and advancing the adoption of clean energies in Indonesia. It also aims to reduce the country’s use of coal.

In a separate collaborative agreement with Keppel Energy, Mitsubishi Power plans to explore the possibility of a 100% ammonia-fired gas turbine on Jurong Island, Singapore. This follows an announcement in August 2022 that Keppel would develop Singapore’s first hydrogen-ready power plant in the Sakra sector of the island, constructed by a consortium including Mitsubishi Power and Jurong Engineering.

The agreement expands on an existing Memorandum of Understanding (MOU) and will allow the partners to collaborate on a common reactor design concept based on Japan’s FR demonstration program and TerraPower’s existing technologies.

Japan’s Strategic Roadmap for FR technology identifies SFR as a promising technology. In July 2023, the Japanese government selected a 650MW pool-type SFR concept proposed by MFBR as the design to be developed, and MHI as the main manufacturer and constructor.

Bill Gates-backed TerraPower is currently developing the Natrium reactor in the United States, with the support of the US Department of Energy (DOE) through the Advanced Reactor Demonstration Program (ARDP).

TerraPower president and CEO Chris Levesque commented: “In order to achieve our climate goals, countries across the world are going to need to deploy advanced reactors starting in the 2030s, and this agreement will help us evaluate the design opportunities for large-scale Natrium plants that can support Japan’s carbon targets.”

MHI executive vice president Akihiko Kato said, “MHI group, as the core company in charge of design and development of the Japanese demonstration fast reactor, will steadily proceed in accordance with the strategic roadmap. We would like to contribute to fast reactor development cooperation between the US and Japan by utilizing the technology and experience we have cultivated over many years.”

Natrium reactor concept

GE Hitachi and TerraPower collaborated to develop the sodium fast reactor combined with a molten salt energy storage system.

The system features a 345MWe reactor, and thermal storage that has the potential to boost the system’s output to 500MWe of power for more than five and a half hours when needed.

According to TerraPower, this allows for a nuclear design that follows daily electric load changes and helps customers capitalize on peaking opportunities driven by renewable energy fluctuations.

The company is developing the Natrium Reactor Demonstration Project, which is being developed in Kemmerer, Wyoming, near a retiring coal plant. The simulator will be able to replicate normal operation and plant protective functions, which the company said offers opportunities to integrate system functions and perform virtual commissioning in the early stages.

Originally published by Pamela Largue in Power Engineering International.

According to the industrial technology specialists, the test achieved stable combustion with up to 50 vol% hydrogen admixture without losing the rated output.

The test was performed to alter the KU series gas engine cogeneration system into a system of less emissions but with the same output.

In this testing phase, the Mitsubishi Heavy Industries (MHI) team addressed issues such as engine knocking caused by hydrogen’s faster flame propagation speed and preignition combustion caused by the lower minimum ignition energy of hydrogen. The team succeeded in maintaining stable combustion by adjusting the excess air ratio and other parameters.

Consequently, the team was able to verify stable combustion of hydrogen admixture of a maximum of 50 vol% while keeping the rated output. It suggests the cogeneration system with the original 5.75MW engine would generate the same result.

Furthermore, the testing revealed that the cogeneration system that generates power and steam is likely to satisfy a CO2 emission coefficient of 0.27kg- CO2/kWh without recovering energy for hot water.

Mitsubishi Heavy Industries Engine & Turbocharger (MHIET) is currently finalizing specifications of auxiliary equipment to be installed together with the engine and control systems of all related equipment with the aim to commercialize in 2025.

This project is aligned with MHI’s goal to achieve net zero CO2 emissions from the entire group by 2040. To this end, MHIET has been focused on the development and commercialization of hydrogen engines, which is listed as a key strategy in its roadmap to carbon neutrality.

Originally published in Power Engineering International.

Located in Nagasaki city, Japan, the new base will be progressively expanded over the coming years.

Nagasaki Carbon Neutral Park will focus mainly on the development of fuel production and carbon capture technologies, with research being conducted at the Nagasaki District Research & Innovation Center.

Applying the thermal energy system design and manufacturing capabilities developed at Nagasaki Shipyard & Machinery Works’ Nagasaki and Koyagi plants, Nagasaki Carbon Neutral Park will accelerate R&D toward product commercialisation and business viability.

In the area of hydrogen production, development will focus on next-generation technologies such as advanced water electrolyzers that operate by solid oxide electrolysis cells (SOEC), and turquoise hydrogen produced by pyrolysis of methane into hydrogen and solid carbon.

Technologies developed at Nagasaki Carbon Neutral Park will subsequently undergo hydrogen production demonstration at Takasago Hydrogen Park in Hyogo Prefecture, as well as demonstration of power generation in combination with a hydrogen gas turbine.

In the area of biomass fuel production, development will target the commercialisation of synthetic fuel production facilities, including sustainable aviation fuels (SAF) produced by biomass gasification integrated Fischer-Tropsch synthesis.

Fischer-Tropsch (FT) synthesis refers to a technology whereby solid materials such as wood cellulose are reacted with water vapor and a small amount of oxygen in a gasifier to produce carbon monoxide and hydrogen (gasification), which are then synthesized into liquid hydrocarbons (fuel) in an FT reactor using a catalyst.

In the area of ammonia combustion, testing will be performed using an actual size burner of a large-scale combustion test furnace located within the Nagasaki district, with plans calling for co-firing with at least 50% ammonia demonstration testing at a power plant in FY2024 or soon thereafter.

Originally published by Power Engineering International.

Commercial operation will start from 2029 after which Mitsubishi Power will provide support according to the long-term service agreement also signed.

This project, totaling 1,950 MW, is a joint venture between Mitsubishi Heavy Industries (MHI) and Mitsubishi Electric Corporation. MHI will supply gas turbines, steam turbines, heat recovery steam generators and flue gas desulfurization systems and Mitsubishi Electric will provide the generators and electrical products.

The M701JAC gas turbines will generate the bulk of the power.

According to MHI, the gas turbines will be capable of hydrogen co-firing and the plant will be designed so that it can be converted to 100% hydrogen firing with minimal rebuilding.

This project will help to alleviate the power supply shortages during Japan’s high-load periods.

The Chiba-Sodegaura Power Co. was established in 2015 by Idemitsu Kosan Co., Kyushu Electric Power Company Inc., and Tokyo Gas Co., Ltd. The company’s initial remit was to promote the development of coal-fired power plants, as well as biomass and mixed combustion power in the region.

According to the International Energy Agency, natural gas in Japan’s total energy mix has increased significantly over the past decade, due to growing demand from the electricity generation sector.

Natural gas has also become more popular since the 2011 Fukushima nuclear accident, which resulted in the closure of all nuclear plans. Japan’s domestic production of gas is still very limited, bringing the dependence on imports to over 90%, states the IEA.

Originally published by Power Engineering International.

MHI will oversee both the conceptual design as well as research and development (R&D) for the sodium-cooled fast reactor in partnership with Mitsubishi FBR Systems, Inc., an MHI Group engineering company that handles the development and design of fast reactors. The conceptual design work is scheduled to start in fiscal 2024.

In a “strategic roadmap” for fast reactor development adopted by the Japanese government in late 2018, a policy was defined to assess the efficacy of various types of fast reactors to be developed following a technological competition among private-sector corporations.

The roadmap was updated at the end of 2022 to reflect two decisions. First, to select a sodium-cooled fast reactor as the target of the conceptual design of the demonstration reactor, set to get underway in fiscal 2024. Second, to select a manufacturer to serve as the core company in charge of the fast reactor’s design and R&D.

MHI already is also involved in a U.S.-Japan cooperation program aimed at enabling faster reactor development and establishing in-house sodium testing facilities. MHI said it is continuing to refine its technologies and develop the necessary human resource to support this important initiative.

And yet we still need more storage. In order to keep the world on track to meet the UN Sustainable Development Goals (SDGs) on energy, the sector needs to see double-digit growth, according to the International Energy Agency (IEA), because of its ability to level out the intermittent nature of renewable sources and respond rapidly to fluctuating demand.

Hydrogen is being considered as an option for energy storage, as an alternative to lithium-ion batteries. So, the question that ponders on our mind is whether hydrogen will be the next viable solution for long term storage?

The relationship between hydrogen and renewables – the potential for energy storage

An almost symbiotic relationship is emerging between hydrogen and renewables. As wind turbines and solar PV panels become cheaper, so does the cost of producing green hydrogen from renewables through electrolysis.

Hydrogen offers the potential for energy storage — it complements battery solutions to provide flexibility to the grid, delivering energy on a much larger scale. Hydrogen can harness surplus renewable energy and store it for long durations, to help smooth out intermittency issues, seasonal power supply imbalances and avoid extended periods of wind or solar curtailment.

As mentioned, this is a particular advantage when there are large seasonal variations in the level of electricity generated by renewables and can help capture energy that might otherwise be wasted. For example, hydrogen storage could be used to capture the excess electricity generated by offshore windfarms during the North Sea’s fierce winter winds.

As renewable energy is generated on a use-it-or-lose-it basis, surplus energy is currently either wasted or curtailed by switching off wind turbines, for example. Hydrogen provides a unique storage solution that can utilize this surplus, which produces no CO₂ emissions when combusted.

Once excess supply of clean energy is converted into green hydrogen, it can power gas turbines and generate electricity as and when required.

This sustainable alternative to natural gas and other fossil fuels can be used to generate baseload backup power during periods of peak energy grid demand. It is also suitable for ironing out short- or long-duration intermittency imbalances associated with renewables when there is too little wind or sun to generate sufficient supply.

Renewable energy can be converted to hydrogen, stored until it is needed, and then reverted to electricity on demand. One of hydrogen’s advantages is its scalability, particularly as an enabler of long-term seasonal storage.

In the western US, for instance, there is often a large renewable energy surplus in the spring, when a combination of strong winds, sunlight and cool temperatures can lead to an excess equal to hundreds of thousands of megawatt hours.

As nodded to previously, it’s a similar situation in the North Sea, where vast offshore wind farms often generate excess energy. There are already a number of projects in development to harness that energy, including the Hamburg Green Hydrogen Hub in Germany, which will produce hydrogen from wind and solar power.

The Hydrogen Council, a global partnership launched at the World Economic Forum Annual Meeting in 2017, says that hydrogen could enable the deployment of renewables by converting and storing more than 500 TWh of electricity.

Crucially, hydrogen also can also help to deliver carbon-free electricity when renewable energy systems (RES) are not producing. This serves to increase security of supply and can help regions such as Europe gain more energy independence in light of geopolitical tensions and uncertainty.

Hydrogen will also bridge regions with high RES potential around the world with industrial centers of energy demand — again, Europe comes to mind.

In order to achieve this, we will have to build a global hydrogen supply infrastructure, in which hydrogen carriers such as ammonia will play an important role by enabling the energy to be transmitted efficiently and safely across long distances.

The Advanced Clean Energy Storage Project

Mitsubishi Power, in partnership with Magnum Renewable Development, is building the world’s largest renewable energy storage project, called Advanced Clean Energy Storage Project in Utah in the United States.  

Renewable hydrogen will be produced from excess renewable energy and stored in a series of underground salt caverns. One cavern at the Advanced Clean Energy Storage project will store enough renewable hydrogen to provide 150,000 MWh of clean energy storage. The location of the project is important for two reasons.

First, it sits on salt caverns that can be used for compressed hydrogen and compressed air energy storage. Second, it’s being built next to the Intermountain Power Plant, a 1.8GW coal-fired power plant that supplies one-fifth of Los Angeles’ electricity and is due for retirement in 2025.

This location means the project will be able to easily connect with the existing electricity transmission infrastructure. It also potentially removes the need for long-distance hydrogen pipelines, as the Intermountain Power Renewal Project will be adjacent to the Advanced Renewable Energy Storage project.

Large-capacity, long-term energy storage and usage needs are growing as renewables spread. Accelerating decarbonization is required even in industries that face challenges electrifying.

Hydrogen and other clean fuels offer solutions. Creating enough future storage capacity for clean alternative fuels, like green hydrogen, is a crucial step in achieving net zero emissions. Hydrogen can store surplus renewable energy, which can then be used as a clean fuel source to help decarbonize power generation or hard-to-abate sectors like transportation and heavy industry.

Hydrogen can help strengthen security of supply, which goes hand in hand with increased energy independence, particularly in the case of Europe. It will connect those regions with the highest potential for solar and wind with demand centers elsewhere, increasing overall efficiency.

Hydrogen alongside other options will be a key element of decarbonising the energy system as a whole – both as a storage medium for renewable energy as well as a fuel to decarbonise those sectors that cannot be simply electrified.

Professor Emmanouil Kakaras is Director of the Laboratory of Steam Boilers and Thermal Plants at the National Technical University of Athens, and Executive Vice-President of NEXT Energy Business at Mitsubishi Heavy Industries EMEA.

On over 1 million square meters of land there are more than 30 office buildings, machining shops and test facilities, as well as several gigantic assembly sheds, each as big as a conventional factory.

Almost 5,000 employees, Japanese and international, work, eat and live here, with all their needs catered to; there is even a Muslim prayer room. For visitors like us, the impression is of relentless activity: thrumming machines, busy workers, overwhelming heat and noise — despite our air-conditioned bus (you cannot hope to see Takasago on foot) and our solicitous guides handing us cold drinks.

Monozukuri at its best

Takasago has made many things in its 60-year history, but the key product has always been turbines and today gas turbines, used mostly in power plants, constitute majority of its output.

Like the aeroengines from which they are derived, these turbines consist of three main components: a compressor of rotating blades and vanes that sucks in and compress air; a set of combustors that add and ignite the fuel currently natural gas but in coming years hydrogen and ammonia; and the turbine itself. This, comprised of even bigger blades and vanes, drives the shaft…that rotates the generator…which produces the electricity.

This simplistic description disguises the enormous expertise and precision engineering that goes into designing and machining each of the hundreds of parts that make up a turbine.

Some are metal, others are made from ceramics and a growing number are 3D-printed using a proprietary, patented metal powder. The air flows into the compressor at speeds faster than that of sound, and the surfaces of the compressor blades are coated to reduce friction. And the blades and vanes have dozens of tiny air holes to help cool the 1,650°C heat in the heart of the machine. This being Japan and MHI, every single part is tested, refined, and re-designed in an endless process of ‘kaizen’.

The result is impressive: once a top-of-the-line JAC gas turbine is snugly fitted into its heavy metal casing it is the size of a bus, weighs 600 tons and can generate up to 840MW of power in a combined cycle set-up. That is more than most wind or solar farms and almost as much as an entire nuclear power station. According to Gas Turbine World, the JAC gas turbine is the most efficient and among the most powerful heavy-duty turbines in the world.

Have you read?
Mitsubishi Heavy Industries among investors in hydrogen startup

But there is more to see at Takasago than sheer prowess at ‘monozukuri’ or making things. The site also comprises research, development, design and verification. In fact, it has its own real power station, T-Point 2, where turbines can be exhaustively tested for many months, with the electricity flowing into the local grid of Hyogo prefecture. This level of integration is unique, leading to efficient development and high reliability. No other global company in this industry has a similar facility.

Going clean and green

Modern gas turbines can reduce carbon dioxide emissions by two thirds compared to a conventional coal-fired boiler. But with society focusing on full decarbonisation, MHI has started to develop new models that can co-fire clean fuels like hydrogen: up to 30-50% currently, with the aim of reaching 100% by 2025 for the 40MW class and by 2030 for the 450MW class.

Naturally, Takasago is being tasked with solving the engineering challenges. Hydrogen co-firing mostly just needs different combustors and the hydrogen co-firing has already started at customers’ power plants. In the US, the world’s largest hydrogen fuel blending of 20% was successfully verified at the McDonough-Atkinson plant in June 2022.

Takasago has also started development of ammonia gas turbines. Ammonia is attracting attention as a carbon-free fuel especially in Japan and APAC. However, it requires dedicated combustor development as it has a totally different chemistry from hydrogen.

MORE: Mitsubishi Power builds hydrogen park to test next-gen technologies

A more immediate hurdle is finding enough hydrogen with which to test the new turbines. Right now, hydrogen loaders bring in supplies for an hour-long combustion test. Hence the latest addition to the site will be a ‘hydrogen park’, that will include production (for example, via an electrolyzer), storage and piping that will produce enough of the gas for longer tests.

The final element at Takasago is its TOMONI HUB, from which a team of engineers with high-security clearances monitor more than 180 gas turbines operating at power stations around the world. The amount of big data collected via the TOMONI remote monitoring system is so vast that the team can often alert customers about maintenance issues before they happen. They can also suggest improvements to operating performance that can save millions over the lifetime of a gas turbine.

This dedication to client service is another factor that sets apart the group from its peers. This is appreciated by customers and surely one factor behind MHI achieving global market leadership in heavy-duty gas turbines for Q1 2022, with 36%.

Still, the decision to purchase a major piece of power plant equipment, is a hard one, even for a big customer. The key, our guides told us, is to get them to take a tour: most of those who visit Takasago end up buying.

Republished with permission from the Mitsubishi Heavy Industries Group

About the Author: Daniel Bogler has been a journalist and media executive for more than 25 years, working for international news organisations in Asia, Europe and America.

Electric Hydrogen (EH2), a startup based in Natick, Massachusetts, said it received $198 million from a slate of investors, including Mitsubishi Heavy Industries.

The investment is intended to support the scale-up of EH2’s electrolyzers and their use in the manufacturing and deployment of pilot projects to produce large quantities of green hydrogen for industrial and infrastructure applications.

Industries not amenable to electrification, such as steel and fertilizer, account for more than a third of the world’s total greenhouse gas emissions, according to EH2.

Hydrogen, when produced in places with abundant and clean electricity, is seen as a promising pathway for decarbonizing these industries. EH2’s goal is to help eliminate more than 30% of global greenhouse gas emissions from hard-to-electrify sectors.

MHI joined other EH2 investors, including Breakthrough Energy Ventures, Equinor, Amazon, Honeywell, and Rio Tinto.

MHI said it is working to build a hydrogen value chain through its technologies, plus investment and collaboration with companies such as EH2.